Abstract: Aspects of the present disclosure relate to valve skid apparatus and related methods for wellhead systems. A check block of the check valve includes a check side face that interfaces with a gate side face of a gate block of the gate valve. A pump side block is coupled to the gate valve, and a well side block is coupled to the check valve. A first pressure relief valve is coupled to a top face of the pump side block, and a first bleed-off valve is coupled to a top face of the first pressure relief valve. A second pressure relief valve is coupled to a top face of the well side block, and a second bleed-off valve is coupled to a top face of the second pressure relief valve.

Abstract: An assembly and a method for stopping a fluid flow through a stuck open inflow control device are described. An inflow control valve includes a valve body with an inlet, an inner sleeve, and an outer sleeve, and an actuation mechanism. The inner sleeve is movably coupled to an inner surface of the valve body to control fluid flow through the valve body. The outer sleeve is coupled to an outer surface of the valve body to stop the fluid flow through the inlet when the inner sleeve is stuck open. The outer sleeve is movable from a position allowing fluid flow through the valve body to a locked position stopping fluid flow through the valve body. The actuation mechanism moves the outer sleeve from the position offset from the inlet to the locked position.

Abstract: A flow control mechanism includes a housing defining a through bore and a cavity contiguous with the through bore, and a barrier received within the cavity of the housing. The barrier is moveable between a sealing position in which fluid flow through the housing is permitted in one direction through the housing and blocked in an opposite direction, and a non-sealing position in which the flow control mechanism is configured to receive an attachment member. An actuating mechanism returns the barrier to the sealing position when the attachment member separates. The actuating mechanism may be an elastomeric band that is in a non-stretched state when the barrier is in the sealing position and in a stretched state when the barrier is in the non-sealing position. The barrier returns from the non-sealing position to the sealing position by action of torque of the stretched flexible member as the flexible member returns to the non-stretched state.

Abstract: An inflow control device for controlling a production flow can include an inlet, a vortex chamber, and a flow control chamber. The inlet can extend obliquely relative to the central axis of the device. The vortex chamber can induce a vortical inflow from the inlet. The flow chamber can receive vortical inflow from the vortex chamber. A movable restriction disk within the flow control chamber can restrict the vortical inflow therein.

Abstract: A method and system of monitoring fluid flow in a wellbore. One or more space-distributed temperature input pulses are induced into at least a portion of a fluid in a housing in the wellbore. The housing has at least one cavity and one or more flow ports. A temperature response pulse, caused by the temperature input pulses, are sensed at one or more locations downstream of the cavity and a flow rate of the fluid through the cavity is determined. The flow rate may be determined based on one or more characteristics of the temperature response pulse, and a Retention Time Distribution (RTD) of the cavity.

Abstract: A ball drop two stage valve includes a tubular having a body defined by an outer surface and an inner surface that defines a fluid flow path. A stimulation port is formed in the body. The stimulation port extends through the body. At least one flow port is formed in the body longitudinally spaced from the stimulation port. The at least one flow port extends through the body. A first sleeve is slidingly positioned along the fluid flow path in the body. The first sleeve includes a first ball seat and is selectively positionable to selectively block flow through the stimulation port. A second sleeve is slidingly positioned along the fluid flow path in the body. The second sleeve includes a second ball seat and is selectively positionable to selectively block flow through the flow port and the stimulation port.

Abstract: An orifice valve as disclosed herein produces a high pressure drop in a flowing fluid. A valve body includes a flow restrictor with multiple flow orifices or ports. The flow ports produce fluid jets. The flow ports may be angled relative to the axial centerline of the valve body.

Abstract: A probe card includes a probe seat having upper and lower dies and a probe accommodating hole, a spring probe inserted through the probe accommodating hole and including a spring sleeve having upper and lower non-spring sections, and a circuit board disposed on the upper die and having a contact pad against which the spring probe is abutted. At least one of the upper and lower dies has a stopping surface partially facing the probe accommodating hole and an extended portion inserting hole in alignment with the probe accommodating hole. At least one of the upper and lower non-spring sections has a cylinder portion abutted on the stopping surface and an extended portion inserted through the extended portion inserting hole.

Abstract: It is sometimes desirable to differentially regulate fluid flow in a subterranean formation using autonomous inflow control devices (AICDs), but they are not readily configurable in the field at present. Wellbore systems providing adjustable flow control may comprise: a wellbore pipe having a flow control assembly fixedly coupled thereto, the wellbore pipe having an interior space, an outer surface, and one or more AICDs establishing a fluid connection between the interior space and the outer surface of the wellbore pipe, and the flow control assembly comprising one or more flow chambers defined on the outer surface about the one or more AICDs, one or more inlets being fluidly connected to the one or more flow chambers; wherein the one or more inlets are configured to accept a plug for occluding fluid flow therethrough, so as to limit access of a fluid to an entry location of the AICDs.

Abstract: A wellbore completion system includes a container for delivering plugs or other objects to a wellbore. The container includes a sleeve having a sealing surface at a first end and a geared interface at a second, opposing end. The sealing surface includes voids or apertures that align with or obstruct apertures in a diverter plate, depending on the position of the sleeve, to permit or obstruct annular flow around the sleeve, respectively. A ball valve is coupled to the second, opposing end of the sleeve, and has a valve-geared interface that engages the geared interface of the sleeve. A releasable object, such as a cement wiper plug, may be stored within the conduit of the sleeve. The geared interface relates movement of the ball valve to movement of the sleeve, resulting in simultaneous opening of the valve, closing of the annular flow path, and release of the releasable object.

Abstract: A flow meter well tool includes a volumetric well flow meter to be positioned in a wellbore. The volumetric well flow meter includes a hollow cylindrical tubing to be positioned in the wellbore. The tubing splits well fluid through the wellbore into an internal fluid through the volumetric well flow meter and an external fluid through an annulus between the wellbore and the volumetric well flow meter. The hollow cylindrical tubing includes an internal portion, where an internal cross-sectional area of the internal portion is less than an internal cross-sectional area of the hollow cylindrical tubing.

Abstract: An assembly for restricting fluid flow into a completion string of a well and restricting fluids based on one or more fluid characteristics is presented. The assembly includes an adjustable inflow control device. The adjustable inflow control device is for restricting flow of production fluids into the completion string. The assembly also includes a first autonomous inflow control device fluidly coupled to the inflow control device for restricting fluids based on one or more fluid characteristics. Others systems and methods are presented.

Abstract: A production sleeve assembly for use in a wellbore comprises a wellbore tubular, a plurality of fluid pathways configured to provide fluid communication within the downhole component, a plurality of electronic actuators configured to selectively provide fluid communication through one or more of the plurality of fluid pathways, and at least one sensor coupled to the plurality of electronic actuators. One or more of the plurality of electronic actuators are configured to selectively actuate to allow or prevent fluid flow through a corresponding fluid pathway of the plurality of fluid pathways in response to the at least one sensor receiving a suitable signal.

Abstract: A system and method for selectively actuating sliding sleeves in valve sub-members which are placed downhole in a wellbore, via one or more darts inserted into said wellbore, to thereby open a ports or ports in such sub-members to allow fracking of the wellbore. The dart is preferably coupled, or provided with coupling means to permit coupling, to a retrieval tool, which upon the retrieval tool being so coupled allows a bypass valve to be opened to thereby assist in withdrawing the dart from within the valve sub-members. Upward movement of the retrieval tool allows a wedge-shaped member to disengage the dart member from a corresponding actuated sleeve to allow the dart to be withdrawn from the wellbore.

Abstract: Apparatus and methods are described for autonomously controlling fluid flow in a tubular in a wellbore. A fluid is flowed through an inlet passageway into a biasing mechanism. A fluid flow distribution is established across the biasing mechanism. The fluid flow distribution is altered in response to a change in the fluid characteristic over time. In response, fluid flow through a downstream sticky switch assembly is altered, thereby altering fluid flow patterns in a downstream vortex assembly. The method “selects” based on a fluid characteristic, such as viscosity, density, velocity, flow rate, etc. The biasing mechanism can take various forms such as a widening passageway, contour elements along the biasing mechanism, or a curved section of the biasing mechanism passageway. The biasing mechanism can include hollows formed in the passageway wall, obstructions extending from the passageway wall, fluid diodes, Tesla fluid diodes, a chicane, or abrupt changes in passageway cross-section.

Abstract: A technique facilitates controlling fluid flows, such as fluid flows in a downhole well zone or zones. A flow control valve is employed to control a fluid flow and is operationally linked with an injection valve. Actuation of the flow control valve is used to automatically actuate the injection valve between corresponding positions allowing or blocking fluid injection. Closing or opening of the flow control valve thus results in a desired corresponding action of the injection valve, such as blocking flow or allowing flow through the injection valve.

Abstract: A valve collar for use with a fluid actuated downhole tool includes a mandrel having one or more valve cylinders formed in the wall thereof, the valve cylinders formed at an angle to the mandrel. The valve cylinders may be connected to each other, to the interior of the mandrel, and to the fluid actuated downhole tool through end holes, slant shell holes, and radial holes. Each valve cylinder may include a valve assembly inserted thereinto.

Abstract: A drill string element for use in the drilling of a borehole, the drill string element comprising: a main body; and a flow control mechanism, wherein the drill string element defines a first aperture, another aperture and a passage configured to provide a fluid flow path between the first aperture and the other aperture, the first and other apertures provide fluid communication between a volume around the drill string element and the passage, and the flow control mechanism is configured to inhibit the flow of fluid through the passage in a first operating mode and to permit the flow of fluid through the passage in a second operating mode.

Abstract: Embodiments usable within the scope of the present disclosure relate generally to a connector apparatus and methods usable to securely and repeatedly connect a sub-sea fluid conduit to another fluid conduit or well equipment, such as a manifold, a wellhead, a BOP, or other associated items. The disclosed embodiments further relate to systems and methods usable to remotely disconnect the fluid conduit and automatically shut off fluid flow therethrough. The male connector includes a flow control valve adapted to open upon connection with a female connector and to close upon disconnection from the female connector. The female connector is adapted to actuate the flow control valve of the male connector to the open position. The male connector includes a biasing member that actuates the flow control valve of the male connector to the closed position.

Abstract: A tunable pneumatic fracturing system and process useable in some instances to extract oil and gas. Some embodiments provide a pneumatic fracturing tool with an elongated body that (a) contains (i) a propellant supply source intermediate opposed propellant gas discharge assemblies, (ii) a control system, and (iii) a communications port, and (b) has roller assemblies at opposed ends of the body. The tool can be tuned to provide gas pulse amplitudes and frequencies that react with the resonant frequency or other aspect of an adjacent earth formation. Some tool embodiments can variably sweep a rock formation and adjust the pressure pulse amplitude and frequency to disrupt the formation in a more productive manner. Some tools can penetrate vertical bore wells as well non-vertical bore wells. In some systems, the tool is transported and operated by a control truck and can be commanded to download operational data during or after use.

Abstract: Embodiments of the disclosure pertain to a downhole tool useable for isolating sections of a wellbore that includes a mandrel, the mandrel further having a body comprising an external surface, and an inner bore formed therein; a distal end; and a proximate end; wherein the mandrel is made of composite material, wherein a set of shear threads are disposed along a surface of the inner bore at the proximate end. Embodiments of the tool include a slip disposed about the mandrel, wherein the slip comprises a one-piece configuration.

Abstract: A method for performing downhole gas lift operations includes coupling a gas lift valve to a tubing, wherein the gas lift valve includes an actuator, a flow control device disposed in the actuator, and a closure member that is initially in an open position; injecting a gas downhole and exterior to the tubing; urging the gas to enter the tubing via the gas lift valve; and creating a sufficient pressure differential across the gas lift valve to move the actuator, thereby causing the closure member to close the gas lift valve.

Abstract: A depressurization tool is described for use downhole in depressurizing an isolated zone. A decompression chamber containing a compressible fluid volume is described. The opening of the chamber is sealed with a closure that is configured to open upon application of a pressure differential across the opening. When used downhole within an isolated and nonpermeable wellbore zone, excessive ambient pressure will cause the closure to open and allow the chamber to fill with fluid at increased pressure, depressurizing the wellbore zone. The tool is useful in wellbore completion systems that include sliding sleeves.

Abstract: An apparatus for installing two sensing instruments and cables inside of a single tubing string in a wellbore for monitoring well conditions at two different locations includes an upper sensor attached to an inner sleeve seated at a first location in a ported outer sleeve in the tubing string. The upper sensor is allowed to be in pressure communication with the exterior of the tubing string at the first location. A second lower sensor is deployed on a pump down cup (PDC) assembly to a lower depth in the outer sleeve to allow fluid pressures to be monitored at a second location in the wellbore.

Abstract: A downhole actuator typically for a downhole tool such as a valve, and typically for incorporation in a string of tubulars in an oil or gas well has a central axis with radially movable counterweights on opposite sides of the axis, which move radially outward to change the activation state of the actuator. The counterweights are supported by link arms which control the movement of the counterweights in response to centrifugal force created by rotation of the body, for example, during rotary drilling operations of the string. Radial outward movement of the counterweights typically transmits axial forces between sleeves at the upper and lower ends of the counterweights, so when the counterweights move radially outward, the upper and lower sleeves approach one another, which typically triggers the actuator.

Abstract: A valve assembly connectable between first and second downhole components that each have first and second internal flowpaths. The valve assembly comprises a first valve operable to selectively fluidly couple the first internal flowpaths of the first and second downhole components, as well as a second valve operable to selectively fluidly couple the second internal flowpaths of the first and second downhole components.

Abstract: An apparatus for controlling a flow of a fluid between a wellbore tubular and a wellbore annulus may include an inflow control device configured to generate a predetermined pressure drop in the flowing fluid; a plurality of particulate control devices conveying the fluid to the inflow control device; and at least one fluid coupling conveying the fluid from at least one of the particulate control devices to the inflow control device.

Abstract: A well completion system having (i) a completion assembly; (ii) a service tool positioned within the completion assembly, wherein the service tool includes a substantially straight bore central passage from an upper end of the service tool to a lower end of the service tool; and (iii) a one-way valve positioned in an assembly annulus formed between the service tool and an inner surface of the completion assembly.

Abstract: A multi-barrier system includes a first valve and a second valve that are both in fluidic communication with a lower completion. The first valve and the second valve are positioned proximate an uphole extent of the lower completion, and a member in operable communication with the first valve and the second valve. The system is configured such that both the first valve and the second valve are open when the member is in a first position, the first valve is closed and the second valve is open when the member in a second position, the first valve is open and the second valve is closed when the member is in a third position, and the first valve and the second valve are both closed when the member is in a fourth position. The first valve and the second valve are closable in response to retrieval of an upper completion.

Abstract: A well device can include a fluid diode having an interior surface that defines an interior chamber, and an outlet from the interior chamber, with the interior surface operable to direct fluid to rotate in a rotational direction through the outlet, and another fluid diode having an interior surface that defines an interior chamber in fluid communication with the outlet, the second interior surface operable to direct fluid to rotate in the rotational direction in response to receiving the fluid rotating in the rotational direction through the outlet. A method of controlling flow in a well can include communicating fluid through two or more fluid diodes in a flow path between an interior and an exterior of a well device in the well. Communicating the fluid through the fluid diodes can cause the fluid to rotate within the fluid diodes in a same rotational direction.

Abstract: Disclosed are annular flow control devices and their methods of use. One flow control device includes an annular inner shroud coupled to a work string that defines one or more flow ports therein, and an annular outer shroud also coupled to the work string and radially offset from the inner shroud such that a channel is defined between at least a portion of the inner and outer shrouds, the channel being in fluid communication with at least one of the one or more flow ports and configured to restrict a flow rate of a fluid.

Abstract: The present invention relates to an inflow control device for controlling the flow of fluid into a well tubular structure arranged in a borehole, comprising a tubular part for mounting as part of the well tubular structure, an aperture provided in a wall of the tubular part, and a hollow valve member rotatably received inside the tubular part, the hollow valve member comprising an orifice in a wall thereof, and an outer surface of the hollow valve member being spherical and the orifice being adapted to fluidly communicate with the aperture when the inflow control device is in an open position, whereby the aperture is in fluid communication with an inside of the tubular part, wherein the hollow valve member comprises a spherical first valve part and a spherical second valve part adapted to be assembled inside the tubular part.

Abstract: The flow control device includes a flow path, a compensation chamber and a regulator assembly defining a first surface exposed to the flow path and an opposing second surface which is exposed to the compensation chamber. A drive arrangement is provided for moving the regulator assembly to vary the flow path. Fluid flowing through the flow path establishes a pressure which varies across the first surface of the regulator assembly. The compensation chamber is in pressure communication with a localised region of the first surface which is selected to establish a compensation chamber pressure which acts against the second surface of the regulator assembly to bias the regulator assembly in a desired direction. The first surface of the regulator assembly may define a profile configured to minimise the variation in pressure applied over the first surface by action of fluid flowing through the flow path.

Abstract: Well conduit system and methods using a first outer conduit wall and at least one second inner conduit wall positioned through a wellhead to define an annulus with radial loading surfaces extending across the annulus and radially between at least two of the conduit walls to form passageways through subterranean strata concentrically, wherein an inner pipe body of greater outer diameter is inserted into an outer pipe body of lesser inner diameter by elastically expanding the circumference of the outer pipe body and elastically compressing the circumference of the inner pipe body, using a hoop force exerted therebetween. Releasing the hoop force after insertion will release the elastic expansion and compression of the pipe bodies to abut the radial loading surfaces within the annulus for sharing elastic hoop stress resistance and thereby forming a greater effective wall thickness, capable of containing higher pressures than the conduit walls could otherwise bear.

Abstract: A downhole tool capable of performing both perforating and fracturing operations has a valve portion comprising a tubular mandrel having a through bore continuous with a tubing string, and a frac window through the side of the tubular mandrel. An outer sleeve is radially disposed around the tubular mandrel. The outer sleeve includes a sleeve port in a sidewall. The tubular mandrel slides relative to the sleeve by application and release of set down weight on a coiled tubing string. When the valve is closed, there is no fluid communication from the tubing string out of the frac window. When the valve is open, fluid communication from the tubing string through the aligned window and port is enabled. The valve may be installed in a downhole tool having a perforation device, allowing fracturing to be carried out following perforation without the need to trip the tool between fracturing and perforating operations.

Abstract: An apparatus is described for controlling flow of fluid in a subterranean formation based on a selected characteristic of fluid flow, such as viscosity, velocity or density, as that characteristic varies over time. A pathway-dependent resistance assembly, such as a vortex chamber having two inlets and an outlet, provides varying resistance to fluid flow based on the ratio of flow from the inlets, the direction of flow as directed by the inlets, and the characteristic of the fluid. The incoming flow ratio is preferably determined by flowing fluid through a plurality of passageways having differing flow rate responses to fluid having differing characteristics. Fluid of a selected characteristic will encounter lesser resistance to flow across the system, while fluid of an un-favored characteristic will encounter greater resistance to flow. Thus, flow of well fluids can be autonomously restricted as the fluid characteristics change over time.

Abstract: Gas injection control devices are provided, particularly for deployment in a well-bore to control injection of a gas into a tube or pipe to lift a liquid up the tube, such as crude oil for example. A gas control device is described which comprises a housing, and at least two control valve arrangements within the housing. Each arrangement has an inlet for receiving gas from a pressurized supply, an outlet for supplying pressurized gas for injection into the tube, an inlet valve in a fluid path between the inlet and outlet, and an actuator associated with the inlet valve. Each actuator is independently controllable to switch the respective inlet valve between its open and closed configurations. This allows the gas injection to be switched on and off, and facilitates control of the injection gas flow rate.

Abstract: An inflow control device laterally insertable in a wall of a tubular, the inflow control device includes a plug shaped body having a first section and a second section, the first section having an orifice accessible to an interior of the tubular and the second section having an opening accessible to an exterior of the tubular, the orifice in fluid communication with the opening; and a selectable insert insertable into the orifice, the insert having an inner periphery providing a flow path between the exterior and interior of the tubular. Also, included is a production string and adjustable orifice inflow control device combination.

Abstract: Disclosed herein is a hydraulic system. The system includes a chemical injection line and a plurality of tools in operable communication with the chemical injection line that are independently responsive to changes in pressure or flow through the chemical injection line and that are configured to control flow of wellbore fluids.

Abstract: An apparatus usable with a well includes a gas lift valve having a check valve arrangement located between an annulus and a passageway of a tubing. The check valve arrangement is adapted to selectively allow fluid flow from the check valve arrangement from an inlet side of the check valve arrangement to an outlet side of the check valve arrangement, and is biased to prevent a leakage flow through the check valve arrangement from the outlet side to the inlet side. The check valve arrangement is defined by a valve element movable into and out of engagement with a valve seat wherein one of the valve element and the valve seat has a first sealing structure engageable with a second sealing structure on the other of the valve element and the valve seat. At least one of the first and second sealing surfaces include at least one pair of sealing members.

Abstract: An injection mandrel may include a valve controlling the flow of the injection fluid. A valve actuator operatively connected to the valve sequentially generates a first predetermined pressure and a larger second predetermined pressure in the valve. The valve actuator generates the second predetermined pressure in the valve in response to a predetermined change in a pressure at an annulus surrounding the mandrel.

Abstract: A down-hole tool for pressure testing production tubing within a borehole of a well returning the well to production, includes an anti-rotational device comprising a tubular housing having a first end, a second end, an outer surface, and at least one anti-rotational wing disposed on the outer surface of the tubular housing, radially extendable to engage a radial surface of the borehole to anchor the production tubing thereto; a valve for controlling the flow of down-hole fluids within the production tubing, the valve comprising a first valve member fixedly positioned within the tubular housing of the anti-rotational device and a second valve member positionable between a closed position and an open position; and a reactivation device comprising means for axially engaging an axial surface of the borehole, the reactivation device affixed to the first end of the tubular housing, wherein the production tubing may be pressure tested when the valve is in the closed position.

Abstract: A flow control device can include a surface that defines a chamber and includes a side perimeter and opposing end surfaces, a greatest distance between the opposing end surfaces being smaller than a largest dimension of the opposing end surfaces, a first port through one of the end surfaces, and a second port through the surface and apart from the first port, the side perimeter surface being operable to direct flow from the second port to rotate about the first port. Another device can include a cylindroidal chamber for receiving flow through an inlet and directing the flow to an outlet, a greatest axial dimension of the cylindroidal chamber being smaller than a greatest diametric dimension of the cylindroidal chamber, the cylindroidal chamber promoting rotation of the flow based on a characteristic of the inflow through the inlet. The device can have a flow path structure in the cylindroidal chamber.

Abstract: A downhole sealing assembly comprises a sleeve adapted to be mounted on a tubular body disposable within a bore, the sleeve (12) including a swellable material and defining a sealing arrangement comprising inner and outer seals. Swelling of the material radially extends the inner seal into contact with the tubular body and extends the outer seal into contact with the bore. seals.

Abstract: The present invention relates to a production system (1) for producing hydrocarbons from a well (2).

Abstract: A method of modulating information on pressure fluctuations transmitted via a tubular string can include applying pressure to a piston, thereby axially displacing the piston, axially displacing and rotating an intermediate sleeve in response to the piston displacement, rotating an output member in response to the axial displacement and rotation of the intermediate sleeve, and rotating a variable flow restrictor rotor relative to a stator, the rotor being connected to the output member. A mud pulser can include a variable flow restrictor, and an actuator which operates the flow restrictor and modulates information on pressure fluctuations produced by the flow restrictor, the actuator including a piston which displaces axially in response to a pressure differential, an intermediate sleeve which is both rotated and displaced axially by the piston, and an output member which is rotated by both rotation and axial displacement of the intermediate sleeve.

Abstract: A gas-lift valve comprising an elongated vertically orientated tubular body with inlet ports positioned for communication with the inlet ports of a gas-lift valve mandrel, a valve seat and valve port at the upper end of the valve body, a movable gas charged dome positioned within the body below the valve seat, a valve ball assembly attached to the dome, and a collapsible bellows positioned to move the dome and manipulate the valve ball assembly downward onto and off of the valve seat in response to pressure from said inlet ports of the valve body and pressure on the seat and thereby allow injection gas to flow upward through the valve port to exit at the upper end of the valve body. A tubular latch is provided with a removable plug to provide for pressure testing and completion of the well with only one wireline trip.

Abstract: A flow control device comprises a fluid pathway configured to provide fluid communication between an exterior of a wellbore tubular and an interior of the wellbore tubular, a flow restriction disposed in the fluid pathway, a one-way valve disposed in the fluid pathway to substantially block fluid flow from the interior of the wellbore tubular to the fluid pathway and to allow fluid flow from the fluid pathway to the interior of the wellbore tubular, and an inflatable seal disposed between an opening to the interior of the wellbore tubular and the fluid pathway, wherein the inflatable seal is configured to inflate to substantially block the fluid pathway in response to a fluid pressure differential between the interior of the wellbore tubular and the exterior of the wellbore tubular that exceeds a predefined threshold.

Abstract: A valve seal assembly that provides for external pressure to be introduced to an energized seal of a valve, and compress the seal against a gate with enough force to block any paths where sand and chemicals would otherwise travel into valve body cavity or void. The external pressure introduced through pressure fitting makes the parts move like piston forcing the parts to compress together eliminating the machined tolerances or gaps required for the gate to be opened or closed. The compression can be provided by hydraulic pressure devices through injection ports. A separate valve seal assembly can be provided for each face of the gate and both assemblies can be activated when the fluids are flowing (open position) and an upstream valve seal assembly activated when the gate is in a closed position.

Abstract: An apparatus for use in a fluid conduit comprises a plurality of segments arranged along a longitudinal axis, each segment comprising an extendable structure configured for extension in a lateral direction relative to the longitudinal axis, wherein the apparatus is configured for the sequential initiation of lateral extension of the extendable structures of at least two segments. At least two segments may be configured to define different maximum extended dimensions in the lateral direction and may include adjacent support surfaces which provide mutual support for one another when the at least two segments are laterally extended. The apparatus may be configured to form a seal, an anchor, a supporting structure and/or a flow restriction in a fluid conduit.